Crude oil pyrolysis gas resource quantity determination method and device, electronic equipment and storage medium

Abstract

The embodiment of the invention discloses a crude oil pyrolysis gas resource quantity determination method and device, electronic equipment and a storage medium. The method comprises the steps that geological data and experimental data of a work area are acquired, and the crude oil resource quantity of the work area is determined based on the geological data and the experimental data; obtaining work area parameters of the work area, and determining the crude oil cracking gas resource quantity of the work area based on the work area parameters and the crude oil resource quantity; wherein the experimental data is data obtained after a heating rate experiment is carried out on a sample, and the sample comprises a hydrocarbon source rock sample obtained from the work area; wherein the work area parameters comprise parameters describing attributes of the work area. According to the technical scheme provided by the embodiment of the invention, the crude oil cracking gas resource quantity of the ancient oil reservoir can be determined.

Description

Technical Field

[0001] The embodiments of the present invention relate to the technical field of oil and natural gas exploration, and in particular to a method, device, electronic equipment and storage medium for determining the amount of crude oil cracking gas resources. Background Art

[0002] As the burial depth increases, under conditions of high temperature and high pressure, the crude oil in some ancient oil reservoirs may crack to form natural gas, which will further accumulate to form gas reservoirs.

[0003] However, it is currently impossible to determine the amount of crude oil cracking gas resources in ancient oil reservoirs, which needs to be solved urgently. Summary of the invention

[0004] The embodiment of the present invention provides a method, device, electronic equipment and storage medium for determining the amount of crude oil cracking gas resources, so as to realize the determination of the amount of crude oil cracking gas resources in ancient oil reservoirs.

[0005] According to one aspect of the present invention, a method for determining the amount of crude oil cracking gas resources is provided, which may include:

[0006] Obtain geological data and experimental data of the work area, and determine the crude oil resources of the work area based on the geological data and experimental data;

[0007] Obtaining work area parameters of the work area, and determining the crude oil cracking gas resource amount of the work area based on the work area parameters and the crude oil resource amount;

[0008] Among them, the experimental data are the data obtained after the heating rate experiment on the samples, and the samples include the source rock samples obtained from the work area;

[0009] The work area parameters include parameters describing the properties of the work area.

[0010] According to another aspect of the present invention, a crude oil cracking gas resource determination device is provided, which may include:

[0011] A crude oil resource determination module is used to obtain geological data and experimental data of the work area, and determine the crude oil resource of the work area based on the geological data and experimental data;

[0012] A crude oil cracking gas resource quantity determination module is used to obtain the work area parameters of the work area, and determine the crude oil cracking gas resource quantity of the work area based on the work area parameters and the crude oil resource quantity;

[0013] Among them, the experimental data are the data obtained after the heating rate experiment on the samples, and the samples include the source rock samples obtained from the work area;

[0014] The work area parameters include parameters describing the properties of the work area.

[0015] According to another aspect of the present invention, there is provided an electronic device, which may include:

[0016] at least one processor; and

[0017] a memory communicatively connected to at least one processor; wherein,

[0018] The memory stores a computer program executable by at least one processor, and the computer program is executed by at least one processor so that the method for determining the amount of crude oil cracking gas resources provided by any embodiment of the present invention is implemented when the at least one processor executes the computer program.

[0019] According to another aspect of the present invention, a computer-readable storage medium is provided, on which computer instructions are stored, and the computer instructions are used to enable a processor to implement the method for determining the amount of crude oil cracking gas resources provided by any embodiment of the present invention when executed.

[0020] The technical solution of the embodiment of the present invention obtains geological data and experimental data of the work area, and determines the crude oil resources of the work area based on the geological data and the experimental data; obtains the work area parameters of the work area, and determines the crude oil cracking gas resources of the work area based on the work area parameters and the crude oil resources; wherein the experimental data is data obtained after a heating rate experiment is performed on the sample, and the sample includes a source rock sample obtained from the work area; wherein the work area parameters include parameters describing the properties of the work area. The technical solution of the embodiment of the present invention can determine the crude oil cracking gas resources of the work area based on the work area parameters and the crude oil resources, thereby realizing the determination of the crude oil cracking gas resources of the ancient oil reservoir.

[0021] It should be understood that the contents described in this section are not intended to identify the key or important features of the embodiments of the present invention, nor are they intended to limit the scope of the present invention. Other features of the present invention will become easily understood through the following description. BRIEF DESCRIPTION OF THE DRAWINGS

[0022] Figure 1 This is a flow chart of a method for determining the amount of crude oil cracking gas resources provided in Example 1 of the present invention;

[0023] Figure 2 This is a flow chart of a method for determining the amount of crude oil cracking gas resources provided in Embodiment 2 of the present invention;

[0024] Figure 3 This is a flow chart of a method for determining the amount of crude oil cracking gas resources provided in Embodiment 3 of the present invention;

[0025] Figure 4 This is a flow chart of a method for determining the amount of crude oil cracking gas resources provided in Embodiment 4 of the present invention;

[0026] Figure 5This is a flow chart of an optional example of a method for determining the amount of crude oil cracking gas resources provided in Embodiment 4 of the present invention;

[0027] Figure 6 is a structural block diagram of a crude oil cracking gas resource determination device provided in Embodiment 5 of the present invention;

[0028] Figure 7 The present invention is a schematic diagram of the structure of an electronic device for implementing the method for determining the amount of crude oil cracking gas resources according to an embodiment of the present invention. DETAILED DESCRIPTION

[0029] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0030] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchangeable where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. The situations of "target", "original", etc. are similar and will not be repeated here. In addition, the terms "including" and "having" and any of their variations are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0031] Embodiment 1

[0032] Figure 1 This is a flow chart of a method for determining the amount of crude oil cracking gas resources provided in the first embodiment of the present invention. This embodiment is applicable to the case of determining the amount of crude oil cracking gas resources. The method can be executed by the crude oil cracking gas resource determination device provided in the embodiment of the present invention, and the device can be implemented by software and / or hardware. The device can be integrated in an electronic device, and the electronic device can be various user terminals or servers.

[0033] See also Figure 1 The method of the embodiment of the present invention specifically includes the following steps:

[0034] S110, obtaining geological data and experimental data of the work area, and determining the crude oil resource amount of the work area based on the geological data and the experimental data, wherein the experimental data is data obtained after a heating rate experiment is performed on samples, and the samples include source rock samples obtained from the work area.

[0035] The work area can be understood as the area where the source rock is located, or the area where the crude oil cracking gas resource calculation is required; the work area can be a basin, depression, oil and gas migration and accumulation unit, zone or block, etc.; the number of work areas can be one or more. Geological data is the geological data related to the work area; geological data can be determined based on at least one of drilling data, seismic data and previous research results related to geology, etc. The crude oil resource can be understood as the crude oil resource in the work area.

[0036] In the embodiment of the present invention, the scope of the work area can be determined based on the distribution range of the source rock, for example, it can be determined based on the distribution range of the source rock that supplies hydrocarbons in the ancient oil reservoir.

[0037] In an embodiment of the present invention, the experimental data is data obtained after a heating rate experiment is performed on the sample. Specifically, the source rock obtained from the work area can be used as the source rock sample, and based on the source rock sample, at least two groups of experiments with different heating rates can be carried out. Taking the two groups of experiments with different heating rates as an example, the source rock samples of the corresponding groups can be heated at a first preset heating rate and a second preset heating rate, for example, the source rock samples of the corresponding groups can be heated at heating rates of 2°C / h and 20°C / h, respectively, to obtain experimental data. Since the hydrocarbon yields of the source rock samples are different when the heating rates in different groups are different, at least two liquid hydrocarbon and gaseous hydrocarbon yield curves under different heating rate conditions can be obtained as experimental data.

[0038] It should be noted that, when the source rock obtained from the work area meets the preset sample conditions, the source rock is used as the source rock sample; when the source rock obtained from the work area does not meet the preset sample conditions, other source rocks that meet the preset sample conditions and are similar in generation age and / or type to the source rock in the work area can be obtained as the source rock sample. The preset sample conditions may be that the maturity of the source rock sample is within a preset maturity range, the preset maturity range may be, for example, less than 0.8% or less than 1%, etc., and / or, the total organic carbon (TOC) content of the source rock sample is within a preset TOC range, the preset TOC range may be, for example, greater than 1%, etc.

[0039] S120, obtaining work area parameters of the work area, and determining the crude oil cracking gas resources of the work area based on the work area parameters and the crude oil resources, wherein the work area parameters include parameters describing properties of the work area.

[0040] Among them, the work area parameters include parameters describing the properties of the work area, such as parameters of the properties of crude oil, natural gas, asphalt and / or gas reservoir in the work area, etc. In the embodiment of the present invention, the specific content of the work area parameters is not specifically limited; specifically, the work area parameters may include, for example, crude oil cracking rate, natural gas density, natural gas molar mass of natural gas components, crude oil density, asphalt density, crude oil volume coefficient, molar gas constant, gas reservoir temperature and / or gas reservoir initial pressure and compression factor of natural gas components under the initial pressure of the gas reservoir, etc., which are not specifically limited in the embodiment of the present invention. The crude oil cracking gas resources can be understood as the natural gas resources obtained after the crude oil within the work area is cracked into natural gas.

[0041] The technical solution of the embodiment of the present invention obtains geological data and experimental data of the work area, and determines the crude oil resources of the work area based on the geological data and the experimental data; obtains the work area parameters of the work area, and determines the crude oil cracking gas resources of the work area based on the work area parameters and the crude oil resources; wherein the experimental data is data obtained after a heating rate experiment is performed on the sample, and the sample includes a source rock sample obtained from the work area; wherein the work area parameters include parameters describing the properties of the work area. The technical solution of the embodiment of the present invention can determine the crude oil cracking gas resources of the work area based on the work area parameters and the crude oil resources, thereby realizing the determination of the crude oil cracking gas resources of the ancient oil reservoir.

[0042] Embodiment 2

[0043] Figure 2 It is a flow chart of another method for determining the amount of crude oil cracking gas resources provided in the second embodiment of the present invention. This embodiment is optimized based on the above-mentioned technical solutions. In this embodiment, optionally, the work area parameters include at least crude oil cracking rate and natural gas density; the amount of crude oil cracking gas resources is determined based on the work area parameters and the amount of crude oil resources, including: determining the quality of natural gas according to the amount of crude oil resources and the crude oil cracking rate, wherein the quality of natural gas is the quality of natural gas generated after the cracking of crude oil in the work area; determining the volume of natural gas according to the density and quality of natural gas; and determining the amount of crude oil cracking gas resources based on the volume of natural gas. Among them, the explanations of the terms that are the same or corresponding to the above-mentioned embodiments are not repeated here.

[0044] See also Figure 2 The method of this embodiment may specifically include the following steps:

[0045] S210, obtaining geological data and experimental data of the work area, and determining the crude oil resource amount of the work area based on the geological data and the experimental data, wherein the experimental data is data obtained after a heating rate experiment is performed on samples, and the samples include source rock samples obtained from the work area.

[0046] S220: Obtain work area parameters of the work area, wherein the work area parameters include parameters describing properties of the work area, and the work area parameters at least include crude oil cracking rate and natural gas density.

[0047] The crude oil cracking rate is the ratio of the mass of natural gas generated by cracking a unit mass of crude oil to the mass of the original unit mass. The natural gas density is the density of the natural gas generated by the cracking of crude oil in the work area.

[0048] It should be noted that when crude oil of normal density is completely cracked into natural gas, for example, natural gas with methane components, the amount of natural gas with methane components obtained by cracking is between 600 and 720 m3. 3 / t, that is, 430-516 mg / g. In this case, the crude oil cracking rate is between 43.0% and 51.6%. In the embodiment of the present invention, for example, the amount of natural gas obtained by cracking crude oil can be 650 m3 / t. 3 / t, in this case, the crude oil cracking rate is 46.6%.

[0049] In the embodiment of the present invention, the density of natural gas under standard ground conditions, for example, the density of natural gas under the conditions of a temperature of 20° C. and an atmospheric pressure, may be used as the density of natural gas.

[0050] S230. Determine the quality of natural gas based on the crude oil resource amount and the crude oil cracking rate, wherein the quality of natural gas is the quality of natural gas generated after the crude oil in the work area is cracked.

[0051] For example, the formula M g =X m ×N o Determine the natural gas quality M g Among them, M g The unit can be, for example, 10 8 t;N o is the crude oil resources, N o The unit can be, for example, 10 8 t;X m is the crude oil cracking rate.

[0052] S240. Determine the volume of natural gas according to the density and mass of natural gas.

[0053] Among them, the natural gas volume is the volume of natural gas generated after the crude oil in the work area is cracked.

[0054] For example, in combination with the above examples, the formula V g =10 3 ×M g / ρ g Determine the natural gas volume V g Among them, V g The unit can be, for example, 10 8 m 3 ρ g is the natural gas density, ρ g The unit can be kg / m 3 .

[0055] S250. Determine the amount of crude oil cracking gas resources based on the volume of natural gas.

[0056] In the technical solution of the embodiment of the present invention, the working area parameters include at least crude oil cracking rate and natural gas density; the natural gas quality is determined according to the crude oil resource amount and the crude oil cracking rate, wherein the natural gas quality is the quality of the natural gas generated after the crude oil in the working area is cracked; the natural gas volume is determined according to the natural gas density and the natural gas quality; and the crude oil cracking gas resource amount is determined based on the natural gas volume. In the embodiment of the present invention, the crude oil cracking gas resource amount is determined by the crude oil resource amount, the crude oil cracking rate and the natural gas density, and the crude oil cracking gas resource amount of the ancient oil reservoir can be further determined.

[0057] An optional technical solution, the work area parameters also include the natural gas molar mass of the natural gas component, crude oil density, asphalt density, crude oil volume coefficient, molar gas constant, gas reservoir temperature, gas reservoir initial pressure and the compression factor of the natural gas component at the gas reservoir initial pressure; based on the natural gas volume, the crude oil cracking gas resource is determined, including: according to the crude oil cracking rate, the natural gas molar mass of the natural gas component, crude oil density, asphalt density, crude oil volume coefficient, molar gas constant, gas reservoir temperature, gas reservoir initial pressure and compression factor, the natural gas loss coefficient is determined; according to the natural gas loss coefficient and the natural gas volume, the crude oil cracking gas resource is determined.

[0058] Among them, the molar mass of natural gas can be understood as the molar mass of the natural gas component in the work area. For example, when the natural gas component is methane, the molar mass of natural gas can be 16. The natural gas component can be understood as the component of the natural gas in the work area. The natural gas component can be, for example, methane and / or ethane, etc. The crude oil density can be understood as the density of the crude oil in the work area. The asphalt density can be understood as the density of the asphalt in the work area. The crude oil volume coefficient can be understood as the ratio of the volume of crude oil in the work area underground to its volume after degassing on the ground. The gas reservoir temperature can be understood as the temperature of the gas reservoir in the work area. The initial pressure of the gas reservoir can be understood as the pressure of the gas reservoir in the work area before it is put into production and development. The compression factor can be understood as the compression factor of the natural gas component in the work area under the initial pressure of the gas reservoir. The natural gas loss coefficient can be understood as the ratio of the natural gas loss in the work area to the original reserves of the natural gas in the work area. The natural gas loss can be understood as the volume of natural gas lost after the cracking of crude oil in the work area.

[0059] For example, in combination with the above examples, the formula Determine the natural gas loss coefficient λ. Wherein, the unit of λ may be, for example, a decimal; M is the molar mass of the natural gas, and the unit of M may be, for example, g / mol; ρ o is the density of crude oil, ρ o The unit can be, for example, g / m 3 ρ b is the density of asphalt, ρ b The unit can be, for example, g / m 3 ; B oi is the crude oil volume coefficient; R is the molar gas constant, R can be, for example, 8.3145; T is the reservoir temperature, the unit of T can be, for example, K; P i is the initial pressure of the gas reservoir, P i The unit of Z can be Pa, for example; i In the embodiment of the present invention, the above formula can be established on the basis of the ancient carbonate rock constant volume system.

[0060] For example, in combination with the above examples, the formula can be derived through the following process: The specific derivation process is as follows:

[0061] Step 1: Determine the work area for deriving the formula. For example, the Cambrian Longwangmiao Formation gas reservoir in Anyue Gas Field in Sichuan Basin is used as the work area. It should be noted that the Longwangmiao Formation gas reservoir in Anyue Gas Field is a lithologic gas reservoir under the tectonic background. Affected by the differences in lithofacies and karstification, the reservoir has a certain plane heterogeneity. The gas reservoir is divided by a dense layer. Each divided sub-gas reservoir has an independent pressure system, and a single sub-gas reservoir can be regarded as a constant volume system. Therefore, the relevant geological attributes of the work area can be considered as follows: natural gas is natural gas produced by cracking crude oil, and natural gas generated with no or a small amount of kerogen; and the work area belongs to an ancient carbonate rock constant volume system, and the gas reservoir area is equal to the ancient oil reservoir area.

[0062] Step 2: You can use the formula n = M g / M, to determine the amount n of natural gas before the crude oil is cracked and the natural gas is lost. The unit of n may be mol, for example.

[0063] Step 3, you can use formula M g =X m ×N o Determine the natural gas quality M g It should be noted that according to the law of conservation of mass, the mass of natural gas is equal to the mass of cracked crude oil, so the mass of natural gas can be determined by the above formula.

[0064] Step 4: Formula M o =V×ρ o / B oi Determine the crude oil reserves M of the ancient oil reservoir o Among them, M o The unit of V can be, for example, g; V is the total storage space of the gas reservoir. The storage space is a constant in an isochoric system. The unit of V can be, for example, m. 3 .

[0065] Step 5: Formula M can be derived from the formulas in steps 3 and 4. g =X m ×ρ o ×V / B oi .

[0066] Step 6: The formula n=(X m ×ρ o ×V) / (M×B oi ).

[0067] Step 7, you can use the formula V g =VV b The volume of asphalt in the reservoir space V b Subtract to get the natural gas volume V gAmong them, the asphalt volume can be understood as the volume of the reservoir space occupied by asphalt, V b The unit can be m, for example 3 .

[0068] Step 8, you can use the formula V b =(1-X m )×M o / ρ b =(1-X m )×ρ o ×V / (B oi ×ρ b ) to obtain the asphalt volume V b .

[0069] Step 9: Formula V can be derived from the formulas in steps 7 and 8. g =[1-(1-X m )×ρ o / (B oi ×ρ b )]×V.

[0070] Step 10: When the gas reservoir is under isochoric conditions and no natural gas loss occurs, the true gas state equation P can be obtained. o ×V g =Z io ×n×R×T. Among them, P o P is the maximum pressure of the gas reservoir under isochoric conditions without natural gas loss. o The unit of Z can be, for example, pa; io is the compressibility factor of methane at maximum pressure.

[0071] Step 11: The formula can be derived from the formulas of steps 6, 9, and 10.

[0072]

[0073] Step 12: After the gas reservoir is under isochoric conditions and natural gas is lost, the true gas state equation P can be obtained under the current gas reservoir state. i ×V g =Z i ×ni×R×T. Wherein, ni is the amount of natural gas in the current gas reservoir, and the unit of ni may be, for example, mol.

[0074] Step 13: The formula can be derived from the formulas in steps 10 and 12.

[0075] Step 14: According to the above steps, the percentage of natural gas loss to the current gas reservoir material can be obtained as and

[0076] Step 15: According to the above steps, the amount of natural gas loss can be obtained. Among them, V L is the amount of natural gas lost, V L The unit can be, for example, 10 8 m 3 ; G is the current geological reserves of natural gas, and the unit of G can be, for example, 10 8 m 3 .

[0077] Step 16: The formula can be derived from the formulas in steps 11 and 15.

[0078]

[0079] Step 17: According to the above steps, the natural gas loss coefficient λ can be obtained as the natural gas loss amount V L Total amount of cracked gas in ancient oil reservoirs V L +G percentage, so we can get the formula

[0080] Combined with the above examples, taking the Longwangmiao Formation gas reservoir in the Moxi 8 well area of ​​the Moxi block in Anyue gas field as an example, the initial pressure of the gas reservoir in the work area parameters is P i =75.98Mpa, gas reservoir temperature T = 142.15℃, the measured compression factor Z i =1.36, the asphalt density of Longwangmiao Formation coke asphalt ρ b =1.30×10 3 kg / m 3 , and the cleavage rate X m The value is 46.6%. Other parameters in the work area can be selected from the relevant parameters of carbonate reservoirs in Tahe Oilfield, Tarim Basin, such as crude oil density ρ o =0.844×10 3 kg / m 3 , the average formation crude oil volume coefficient B oi =1.227, etc. Substituting the above work area parameters and crude oil cracking rate into the formula in step 17, the natural gas loss coefficient λ=42.07% can be obtained.

[0081] For example, in combination with the above examples, the formula V L =λ×V g And the formula N g =V g -V L , or, Formula N g =V g(1-λ) Determine the crude oil cracking gas resources N g Among them, N g The unit can be, for example, 10 8 m 3 .

[0082] It should be noted that at least one of the natural gas composition, asphalt density, crude oil density, crude oil volume coefficient, gas reservoir temperature, gas reservoir initial pressure and compression factor can be obtained by actual measurement in the work area, or can be measured based on relevant samples collected in the work area.

[0083] In the embodiment of the present invention, the natural gas loss coefficient can be determined according to the crude oil cracking rate, natural gas molar mass, crude oil density, asphalt density, crude oil volume coefficient, molar gas constant, gas reservoir temperature, gas reservoir initial pressure and compression factor; the crude oil cracking gas resource amount can be determined according to the natural gas loss coefficient and natural gas volume. The scheme of the embodiment of the present invention can improve the reliability and accuracy of the determination of the crude oil cracking gas resource amount, and is more practical.

[0084] Embodiment 3

[0085] Figure 3 It is a flow chart of another method for determining the amount of crude oil cracking gas resources provided in Example 3 of the present invention. This embodiment is optimized based on the above-mentioned technical solutions. In this embodiment, optionally, the amount of crude oil resources in the work area is determined based on geological data and experimental data, including: establishing a three-dimensional geological model of the work area based on geological data and experimental data; determining the total oil production and oil potential data of the work area based on the three-dimensional geological model; determining the amount of crude oil resources in the work area based on the total oil production, oil potential data and geological data. Among them, the explanations of the terms that are the same or corresponding to the above-mentioned embodiments are not repeated here.

[0086] See also Figure 3 The method of this embodiment may specifically include the following steps:

[0087] S310, obtaining geological data and experimental data of the work area, wherein the experimental data is data obtained after a heating rate experiment is performed on samples, and the samples include source rock samples obtained from the work area.

[0088] S320. Establish a three-dimensional geological model of the work area based on geological data and experimental data.

[0089] The three-dimensional geological model can be understood as a three-dimensional geological model obtained through three-dimensional geological modeling.

[0090] For example, a three-dimensional geological model of the work area can be established based on geological data and experimental data using a simulation calculation module (PertroMod3D) software.

[0091] S330. Based on the three-dimensional geological model, determine the total oil production and oil potential data of the work area.

[0092] The total oil production can be understood as the amount of crude oil produced in the work area. The unit of the total oil production can be, for example, 10 8 t; The total oil production may include the part that has migrated or dispersed from the oil-producing layer and the part that remains in the source rock. Oil potential data may be understood as data related to the flow direction, enrichment and accumulation of oil and gas. Oil potential data may be, for example, an oil potential map.

[0093] For example, in combination with the above example, the total oil production and oil potential data of the work area can be determined based on the three-dimensional geological model using PertroMod 3D software.

[0094] S340. Determine the crude oil resources in the work area based on the total oil production, oil potential data and geological data.

[0095] S350, obtaining work area parameters of the work area, and determining the crude oil cracking gas resource quantity of the work area based on the work area parameters and the crude oil resource quantity, wherein the work area parameters include parameters describing the properties of the work area.

[0096] The technical solution of the embodiment of the present invention can establish a three-dimensional geological model of the work area based on geological data and experimental data; determine the total oil production and oil potential data of the work area based on the three-dimensional geological model; and determine the crude oil resources of the work area based on the total oil production, oil potential data and geological data. The technical solution of the embodiment of the present invention can reduce the workload of determining the crude oil resources of the work area through the three-dimensional geological model and speed up the determination of the crude oil resources.

[0097] An optional technical solution is to establish a three-dimensional geological model of a work area based on geological data and experimental data, including: obtaining the vitrinite reflectance of the work area; determining the work area data of the work area based on the geological data, wherein the work area data includes at least one of the following: ground topography data, stratigraphic thickness data, stratigraphic age data, source rock thickness data, total organic carbon distribution data of source rocks, erosion data, mixed lithology data, paleo-water depth data, paleo-heat flow data and paleo-geothermal data; determining hydrocarbon generation kinetic parameters based on the experimental data; and establishing a three-dimensional geological model of the work area based on the vitrinite reflectance, hydrocarbon generation kinetic parameters, and the work area data.

[0098] Among them, the work area data can be understood as data related to the geology of the work area. The ground topography data can be understood as data related to the ground topography of the work area. The stratum thickness data can be understood as data related to the stratum thickness of the work area. The stratigraphic age data can be understood as data related to the geological age corresponding to the strata of the work area. The source rock thickness data can be understood as data related to the source rock thickness of the work area. The source rock total organic carbon distribution data can be understood as data related to the total organic carbon distribution of the source rock in the work area. The erosion data can be understood as data related to the erosion of the work area. The mixed lithology data can be understood as data related to the rock characteristics of the work area. The paleowater depth data can be understood as data related to the height difference between the top surface of the sediments in the work area and the sea level deposition base surface in the geological history. The paleoheat flow data can be understood as data related to the heat flow in the work area in the geological history. The paleogeothermal data can be understood as data related to the temperature of the work area in the geological history. The hydrocarbon generation kinetic parameters can be understood as parameters related to the hydrocarbon generation mechanism of organic matter.

[0099] It should be noted that the vitrinite reflectance (R o ) may be obtained by actually measuring the samples collected in the working area. In the embodiment of the present invention, the method for obtaining the vitrinite reflectance of the working area is not specifically limited.

[0100] Exemplarily, the ground topographic data can be determined based on the drilling data, seismic data and data of previous research results related to geology in the geological data. The ground topographic data can be, for example, a ground topographic map; the stratigraphic thickness contour map of each layer in the work area can be drawn as the stratigraphic thickness data based on the drilling data, seismic data and data of previous research results related to geology in the geological data; the geological age corresponding to each set of strata can be determined separately as the stratigraphic age data based on the international chronostratigraphic table data in the geological data; in the embodiment of the present invention, the source rock in the work area that supplies hydrocarbons to the ancient oil reservoir may be one set or multiple sets. Therefore, the stratigraphic thickness contour map of each set of source rocks can be drawn as the source rock thickness data based on the drilling data, seismic data and data of previous research results related to geology in the geological data; the stratigraphic thickness contour map can be drawn as the source rock thickness data based on the actual drilling data in the geological data. The TOC data measured and the geophysical prediction data in the geological data are used to draw a TOC plane distribution map for each set of source rocks as the total organic carbon distribution data of the source rocks; the structural cross-section method can be used based on the cross-section data of the work area in the geological data, the acoustic time difference method can be used based on the drilling data in the geological data, and the vitrinite reflectivity method can be used to restore the erosion amount of each set of strata, so as to determine the erosion amount of each set of strata and compile a plane distribution map of the erosion amount, which can be used to compile a plane distribution map of the erosion amount corresponding to each set of strata, and determine the erosion time corresponding to each plane distribution map of the erosion amount, and use the above-mentioned stratum erosion amount, plane distribution map of the erosion amount and erosion time as erosion data; the mixed lithology data can be determined based on the comprehensive logging data in the drilling data in the geological data, for example, the PertroMod The lithology mixer (CreateMix) module in the 3D software determines the mixed lithology data. The comprehensive logging data can include the pure lithology statistics of single-well sandstone, siltstone, mudstone and carbonate rock; the ancient water depth data can be determined based on the lithofacies paleogeography map in the geological data; the ancient heat flow data and the ancient geothermal data can be determined based on the data of the previous research results related to geology in the geological data, or, the ancient heat flow data and the ancient geothermal data can be determined based on the current ground temperature of the work area through basin simulation software and other software by combining the geothermodynamics method with geochemistry.

[0101] For example, based on the experimental data, the activation energy distribution and frequency factor of oil and gas generation can be calculated by using hydrocarbon generation kinetics data processing software (version: Kinetics05), and the activation energy distribution and frequency factor can be used as hydrocarbon generation kinetics parameters.

[0102] Exemplarily, the top surface of the three-dimensional geological model can be generated according to the ground topographic data through the PertroMod 3D software; from top to bottom, the stratigraphic framework of the three-dimensional geological model can be established according to the stratigraphic thickness data; the stratigraphic framework can be assigned according to the mixed lithology data; at least one of the parameters such as vitrinite reflectance, hydrocarbon generation kinetic parameters, and erosion data, stratigraphic age data, source rock thickness data, total organic carbon distribution data of source rocks, paleo-water depth data, paleo-heat flow data and paleo-geothermal data can be input into the PertroMod 3D software, thereby establishing a three-dimensional geological model.

[0103] In an embodiment of the present invention, after the three-dimensional geological model is established, the three-dimensional geological model can be corrected. Exemplarily, the maturity simulation result of the source rock, i.e., the simulated vitrinite reflectance, can be output based on the three-dimensional geological model through the PertroMod 3D software; at least one typical well that is evenly distributed in the work area and can represent different blocks in the work area is selected in the work area, and in particular, at least three typical wells that are evenly distributed in the work area and can represent different blocks in the work area are selected in the work area, and the measured vitrinite reflectance values ​​of the samples obtained from the typical wells are measured; the measured vitrinite reflectance corresponding to each typical well is compared with the simulated vitrinite reflectance; the denudation amount and / or paleoheat flow value of the three-dimensional geological model is adjusted based on the comparison result, or, based on the comparison result, the input to PertroMod is adjusted. 3D software's denudation data and / or paleoheat flow data; repeat the above adjustment operation until the measured vitrinite reflectance corresponding to each typical well and the simulated vitrinite reflectance can be matched to the maximum extent, and the maximum match can be, for example, a match ratio exceeding a preset ratio, so as to realize correction of the three-dimensional geological model based on the adjustment results.

[0104] In the embodiment of the present invention, the vitrinite reflectance of the work area can be obtained; based on the geological data, the work area data of the work area is determined, wherein the work area data includes at least one of the following: ground topography data, stratum thickness data, stratum age data, source rock thickness data, source rock total organic carbon distribution data, erosion data, mixed lithology data, paleowater depth data, paleoheat flow data and paleogeothermal data; based on the experimental data, the hydrocarbon generation kinetic parameters are determined; based on the vitrinite reflectance, the hydrocarbon generation kinetic parameters, and the work area data, a three-dimensional geological model of the work area is established. The technical solution of the embodiment of the present invention can realize the establishment of a relatively complete and comprehensive three-dimensional geological model of the work area.

[0105] Embodiment 4

[0106] Figure 4It is a flow chart of another method for determining the amount of crude oil cracking gas resources provided in Example 4 of the present invention. This embodiment is optimized based on the above-mentioned technical solutions. In this embodiment, optionally, based on the total oil production, oil potential data and geological data, the amount of crude oil resources in the work area is determined, including: determining the stratigraphic structure data of the work area according to the geological data; dividing the work area according to the oil potential data and the stratigraphic structure data to obtain at least one migration and accumulation unit; determining the unit oil production of each migration and accumulation unit in at least one migration and accumulation unit according to the total oil production; determining the unit migration and accumulation coefficient of each migration and accumulation unit based on the geological data; determining the amount of crude oil resources in the work area according to the unit oil production and the unit migration and accumulation coefficient of each migration and accumulation unit. Among them, the explanations of the terms that are the same or corresponding to the above-mentioned embodiments are not repeated here.

[0107] See also Figure 4 The method of this embodiment may specifically include the following steps:

[0108] S410, obtaining geological data and experimental data of the work area, wherein the experimental data is data obtained after a heating rate experiment is performed on samples, and the samples include source rock samples obtained from the work area.

[0109] S420. Establish a three-dimensional geological model of the work area based on geological data and experimental data.

[0110] S430. Based on the three-dimensional geological model, determine the total oil production and oil potential data of the work area.

[0111] S440. Determine the stratigraphic structure data of the work area based on the geological data.

[0112] The stratigraphic structure data may be understood as data related to the stratigraphic structure of the work area. The stratigraphic structure data may be, for example, stratigraphic structure maps corresponding to each stratum in the work area.

[0113] For example, the stratigraphic structure data of the work area can be determined based on drilling data, seismic data and previous research results related to geology in the geological data.

[0114] S450: Divide the work area according to the oil potential data and the stratigraphic structure data to obtain at least one migration and accumulation unit.

[0115] Among them, the migration and accumulation unit can be understood as a relative geological unit with similar oil and gas migration and accumulation characteristics; the migration and accumulation unit can be delineated by the oil and gas migration segmentation groove and the outer boundary of the maximum oil and gas migration space in the oil potential data, for example.

[0116] In the embodiment of the present invention, a comprehensive analysis can be performed on the work area based on the oil potential data and the formation structure data, and the work area can be divided according to the analysis results to obtain at least one migration and accumulation unit.

[0117] S460: Determine the unit oil production of each transportation and accumulation unit in at least one transportation and accumulation unit according to the total oil production.

[0118] The unit oil generation can be understood as the oil generation of the migration and accumulation unit.

[0119] In the embodiment of the present invention, the unit oil production of each migration and accumulation unit in at least one migration and accumulation unit may be determined according to the total oil production and / or the division method of the migration and accumulation units or the analysis result obtained by comprehensive analysis of the work area.

[0120] S470. Determine the unit migration coefficient of each migration unit based on the geological data.

[0121] The unit migration and accumulation coefficient can be understood as the migration and accumulation coefficient of the migration and accumulation unit. The migration and accumulation coefficient can be understood as the ratio of the oil and gas resources to the hydrocarbon generation in a certain geological unit.

[0122] S480. Determine the crude oil resource volume of the work area according to the unit oil production of each migration and accumulation unit and the unit migration and accumulation coefficient.

[0123] For example, the formula Determine the crude oil resources N o Among them, Q i is the unit oil generation of the migration and accumulation unit, Q i The unit can be, for example, 10 8 t; K i is the unit aggregation coefficient of the aggregation unit, K i The unit of can be a decimal, for example; n is the number of aggregation units.

[0124] S490, obtaining work area parameters of the work area, and determining the crude oil cracking gas resource quantity of the work area based on the work area parameters and the crude oil resource quantity, wherein the work area parameters include parameters describing the properties of the work area.

[0125] The technical solution of the embodiment of the present invention determines the stratigraphic structure data of the work area according to the geological data; divides the work area according to the oil potential data and the stratigraphic structure data to obtain at least one migration and accumulation unit; determines the unit oil production of each migration and accumulation unit in at least one migration and accumulation unit according to the total oil production; determines the unit migration and accumulation coefficient of each migration and accumulation unit based on the geological data; determines the crude oil resource amount of the work area according to the unit oil production and the unit migration and accumulation coefficient of each migration and accumulation unit. In the embodiment of the present invention, the workload of determining the crude oil resource amount of the work area can be further reduced, and the speed of determining the crude oil resource amount can be accelerated.

[0126] An optional technical solution, based on geological data, determines the unit migration coefficient of each migration unit, including: based on the geological data, determining a scale unit from at least one migration unit; based on the geological data, determining the scale resource of the scale unit by statistical method or analogy method, wherein the scale resource is the resource of crude oil in the scale unit; according to the scale resource and the scale oil production of the scale unit, determining the scale migration coefficient of the scale unit, wherein the scale oil production is the unit oil production of the scale unit; based on the scale migration coefficient and the geological data, determining the unit migration coefficient of each migration unit.

[0127] The scale unit can be understood as a unit determined from at least one convergence unit and used as a reference scale. The scale convergence coefficient is the unit convergence coefficient of the scale unit.

[0128] In an embodiment of the present invention, based on at least one of the drilling data, seismic data and previous research results related to geology in the geological data, a migration unit with a high degree of exploration, clear geological understanding, clear resource abundance and / or distribution can be determined from at least one migration unit as a calibration unit.

[0129] In an embodiment of the present invention, the scale resource volume of the scale unit can be determined by a statistical method or an analogy method based on at least one of the drilling data, seismic data and data of previous research results related to geology in the geological data; the scale resource volume can be divided by the scale oil production to obtain the scale migration coefficient of the scale unit; based on the geological data, at least one of the geological factors such as hydrocarbon generation conditions, reservoir conditions, closure conditions, preservation conditions and supporting conditions can be used as an analogy parameter to compare the scale unit with each other migration unit in other migration units except the scale unit, and determine the analogy coefficients corresponding to the other migration units according to the comparison results, the analogy coefficient is a coefficient that can reflect the ratio between the scale migration coefficient of the scale unit and the unit migration coefficients of other migration units; for each migration unit in other migration units, the product of the scale migration coefficient and the analogy coefficients corresponding to the other migration units is determined, and the product is used as the unit migration coefficient of the other migration units.

[0130] In the embodiment of the present invention, the unit concentration coefficient may be obtained by estimation or regression formula or calculated by analogy with the scale area, and so on.

[0131] In an embodiment of the present invention, a scale unit can be determined from at least one migration and accumulation unit based on geological data; based on the geological data, the scale resource quantity of the scale unit can be determined by a statistical method or an analogy method, wherein the scale resource quantity is the resource quantity of crude oil in the scale unit; based on the scale resource quantity and the scale oil production of the scale unit, the scale migration and accumulation coefficient of the scale unit can be determined, wherein the scale oil production is the unit oil production of the scale unit; based on the scale migration and accumulation coefficient and the geological data, the unit migration and accumulation coefficient of each migration and accumulation unit can be determined, so as to obtain a more accurate unit migration and accumulation coefficient.

[0132] In order to better understand the technical solution of the above embodiment of the present invention, an optional example is provided here. Figure 5 , determine the scope of the work area based on the distribution range of the source rock; draw the thickness contour map of each layer in the work area based on the geological data; draw the thickness contour map of each set of source rocks and the TOC content plane map based on the geological data; determine the erosion amount and erosion time of each set of strata based on the geological data; conduct thermal simulation experiments on the samples to obtain the hydrocarbon generation kinetic parameters; based on the geological data, paleo-water depth data, paleo-geothermal data and paleo-heat flow data; based on the thickness contour map of each layer, the thickness contour map of each set of source rocks, the TOC content plane map, the erosion amount and erosion time of each set of strata, the hydrocarbon generation kinetic parameters, the paleo-water depth data, the paleo-geothermal data and the paleo-heat flow data Establish a three-dimensional geological model based on deep data, paleogeothermal data and paleoheat flow data; calibrate the three-dimensional geological model; obtain total oil generation and oil potential data based on the corrected three-dimensional geological model; determine the unit migration and accumulation coefficients corresponding to the divided migration and accumulation units based on the geological data, total oil generation and oil potential data; determine the crude oil resources in the work area based on the unit migration and accumulation coefficients; determine the crude oil cracking gas resources based on the crude oil resources and crude oil cracking rate; calculate the natural gas loss based on the formula corresponding to the calculation of the natural gas loss coefficient; obtain the crude oil cracking gas resources based on the crude oil cracking gas resources and the natural gas loss.

[0133] Embodiment 5

[0134] Figure 6 1 is a block diagram of a crude oil cracking gas resource determination device provided in Embodiment 5 of the present invention, and the device is used to execute the crude oil cracking gas resource determination method provided in any of the above embodiments. The device and the crude oil cracking gas resource determination method of the above embodiments belong to the same inventive concept, and the details not described in detail in the embodiment of the crude oil cracking gas resource determination device can refer to the embodiment of the above crude oil cracking gas resource determination method. Figure 6 The device may specifically include: a crude oil resource quantity determination module 510 and a crude oil cracking gas resource quantity determination module 520.

[0135] The crude oil resource determination module 510 is used to obtain geological data and experimental data of the work area, and determine the crude oil resource of the work area based on the geological data and experimental data;

[0136] The crude oil cracking gas resource quantity determination module 520 is used to obtain the work area parameters of the work area, and determine the crude oil cracking gas resource quantity of the work area based on the work area parameters and the crude oil resource quantity;

[0137] Among them, the experimental data are the data obtained after the heating rate experiment on the samples, and the samples include the source rock samples obtained from the work area;

[0138] The work area parameters include parameters describing the properties of the work area.

[0139] Optionally, the work area parameters include at least crude oil cracking rate and natural gas density;

[0140] The crude oil cracking gas resource determination module 520 may include:

[0141] A natural gas quality determination unit, used to determine the natural gas quality according to the crude oil resource and the crude oil cracking rate, wherein the natural gas quality is the quality of the natural gas generated after the crude oil in the work area is cracked;

[0142] A natural gas volume determination unit, used for determining the natural gas volume according to the natural gas density and the natural gas quality;

[0143] The crude oil cracking gas resource determination unit is used to determine the crude oil cracking gas resource based on the natural gas volume.

[0144] On the basis of the above scheme, optionally, the work area parameters also include natural gas molar mass of natural gas components, crude oil density, asphalt density, crude oil volume coefficient, molar gas constant, gas reservoir temperature, gas reservoir initial pressure and compressibility factor of natural gas components at the gas reservoir initial pressure;

[0145] The crude oil cracking gas resource determination unit may include:

[0146] A natural gas loss coefficient determination subunit is used to determine the natural gas loss coefficient according to the crude oil cracking rate, natural gas molar mass, crude oil density, asphalt density, crude oil volume coefficient, molar gas constant, gas reservoir temperature, gas reservoir initial pressure and compression factor;

[0147] The crude oil cracking gas resource determination subunit is used to determine the crude oil cracking gas resource based on the natural gas loss coefficient and the natural gas volume.

[0148] Optionally, the crude oil resource determination module 510 may include:

[0149] A three-dimensional geological model building unit is used to build a three-dimensional geological model of the work area based on geological data and experimental data;

[0150] An oil potential data determination unit is used to determine the total oil production and oil potential data of the work area based on the three-dimensional geological model;

[0151] The crude oil resource determination unit is used to determine the crude oil resource of the work area based on the total oil production, oil potential data and geological data.

[0152] Based on the above scheme, optionally, the three-dimensional geological model building unit may include:

[0153] The vitrinite reflectance acquisition subunit is used to obtain the vitrinite reflectance of the work area;

[0154] A work area data determination subunit is used to determine the work area data of the work area based on the geological data, wherein the work area data includes at least one of the following: ground topography data, stratum thickness data, stratum age data, source rock thickness data, source rock total organic carbon distribution data, erosion data, mixed lithology data, paleo-water depth data, paleo-heat flow data, and paleo-geothermal data;

[0155] A hydrocarbon generation kinetic parameter determination subunit, used to determine hydrocarbon generation kinetic parameters based on experimental data;

[0156] The three-dimensional geological model building subunit is used to build a three-dimensional geological model of the work area based on vitrinite reflectance, hydrocarbon generation dynamics parameters, and work area data.

[0157] Based on the above solution, optionally, the crude oil resource determination unit may include:

[0158] The stratigraphic structure data subunit is used to determine the stratigraphic structure data of the work area based on the geological data;

[0159] The migration and accumulation unit obtains subunits, which are used to divide the work area according to the oil potential data and the stratigraphic structure data to obtain at least one migration and accumulation unit;

[0160] A unit oil production determination subunit is used to determine the unit oil production of each migration and accumulation unit in at least one migration and accumulation unit according to the total oil production;

[0161] A unit migration coefficient determination subunit is used to determine the unit migration coefficient of each migration unit based on geological data;

[0162] The crude oil resource determination subunit is used to determine the crude oil resource of the work area according to the unit oil production and unit migration and accumulation coefficient of each migration and accumulation unit.

[0163] On the basis of the above scheme, optionally, the unit aggregation coefficient determines the subunit, which is specifically used for:

[0164] Determining a scale unit from at least one migration unit based on the geological data;

[0165] Based on the geological data, the scale resource of the scale unit is determined by statistical method or analogy method, wherein the scale resource is the resource of crude oil in the scale unit;

[0166] Determine the scale migration and accumulation coefficient of the scale unit according to the scale resource volume and the scale oil production volume of the scale unit, wherein the scale oil production volume is the unit oil production volume of the scale unit;

[0167] Based on the scaled migration coefficient and geological data, the unit migration coefficient of each migration unit is determined.

[0168] The crude oil cracking gas resource determination device provided in the fifth embodiment of the present invention obtains geological data and experimental data of the work area through the crude oil resource determination module, and determines the crude oil resource of the work area based on the geological data and the experimental data; obtains the work area parameters of the work area through the crude oil cracking gas resource determination module, and determines the crude oil cracking gas resource of the work area based on the work area parameters and the crude oil resource; wherein the experimental data is data obtained after a heating rate experiment is performed on the sample, and the sample includes a source rock sample obtained from the work area; wherein the work area parameters include parameters describing the properties of the work area. The above device can determine the crude oil cracking gas resource of the work area based on the work area parameters and the crude oil resource, thereby realizing the determination of the crude oil cracking gas resource of the ancient oil reservoir.

[0169] The crude oil cracking gas resource quantity determination device provided in the embodiment of the present invention can execute the crude oil cracking gas resource quantity determination method provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects of the execution method.

[0170] It is worth noting that in the embodiment of the above-mentioned crude oil cracking gas resource determination device, the various units and modules included are only divided according to functional logic, but are not limited to the above-mentioned division, as long as the corresponding functions can be achieved; in addition, the specific names of the functional units are only for the convenience of distinguishing each other, and are not used to limit the scope of protection of the present invention.

[0171] Embodiment 6

[0172] Figure 7A schematic diagram of the structure of an electronic device 10 that can be used to implement an embodiment of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processing, cellular phones, smart phones, wearable devices (such as helmets, glasses, watches, etc.) and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely examples and are not intended to limit the implementation of the present invention described and / or required herein.

[0173] like Figure 7 As shown, the electronic device 10 includes at least one processor 11, and a memory connected to the at least one processor 11, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., wherein the memory stores a computer program that can be executed by at least one processor, and the processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or the computer program loaded from the storage unit 18 to the random access memory (RAM) 13. In the RAM 13, various programs and data required for the operation of the electronic device 10 can also be stored. The processor 11, the ROM 12, and the RAM 13 are connected to each other through a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0174] A number of components in the electronic device 10 are connected to the I / O interface 15, including: an input unit 16, such as a keyboard, a mouse, etc.; an output unit 17, such as various types of displays, speakers, etc.; a storage unit 18, such as a disk, an optical disk, etc.; and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices through a computer network such as the Internet and / or various telecommunication networks.

[0175] The processor 11 may be a variety of general and / or special processing components with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any appropriate processor, controller, microcontroller, etc. The processor 11 executes the various methods and processes described above, such as a method for determining the amount of crude oil cracking gas resources.

[0176] In some embodiments, the crude oil cracking gas resource determination method can be implemented as a computer program, which is tangibly contained in a computer-readable storage medium, such as a storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the crude oil cracking gas resource determination method described above can be performed. Alternatively, in other embodiments, the processor 11 can be configured to perform the crude oil cracking gas resource determination method in any other appropriate manner (for example, by means of firmware).

[0177] Various implementations of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), systems on chips (SOCs), load programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various implementations can include: being implemented in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which can be a special purpose or general purpose programmable processor that can receive data and instructions from a storage system, at least one input device, and at least one output device, and transmit data and instructions to the storage system, the at least one input device, and the at least one output device.

[0178] Computer programs for implementing the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, so that when the computer program is executed by the processor, the functions / operations specified in the flow chart and / or block diagram are implemented. The computer program may be executed entirely on the machine, partially on the machine, partially on the machine as a stand-alone software package and partially on a remote machine, or entirely on a remote machine or server.

[0179] In the context of the present invention, a computer-readable storage medium may be a tangible medium that may contain or store a computer program for use by or in combination with an instruction execution system, device or equipment. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, devices or equipment, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. A more specific example of a machine-readable storage medium may include an electrical connection based on one or more lines, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing.

[0180] To provide interaction with a user, the systems and techniques described herein may be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and a pointing device (e.g., a mouse or trackball) through which the user can provide input to the electronic device. Other types of devices may also be used to provide interaction with the user; for example, the feedback provided to the user may be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user may be received in any form (including acoustic input, voice input, or tactile input).

[0181] The systems and techniques described herein may be implemented in a computing system that includes backend components (e.g., as a data server), or a computing system that includes middleware components (e.g., an application server), or a computing system that includes frontend components (e.g., a user computer with a graphical user interface or a web browser through which a user can interact with implementations of the systems and techniques described herein), or a computing system that includes any combination of such backend components, middleware components, or frontend components. The components of the system may be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include: a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0182] A computing system may include a client and a server. The client and the server are generally remote from each other and usually interact through a communication network. The client and server relationship is generated by computer programs running on the corresponding computers and having a client-server relationship with each other. The server may be a cloud server, also known as a cloud computing server or cloud host, which is a host product in the cloud computing service system to solve the defects of difficult management and weak business scalability in traditional physical hosts and VPS services.

[0183] It should be understood that the various forms of processes shown above can be used to reorder, add or delete steps. For example, the steps described in the present invention can be executed in parallel, sequentially or in different orders, as long as the desired results of the technical solution of the present invention can be achieved, and this document does not limit this.

[0184] The above specific implementations do not constitute a limitation on the protection scope of the present invention. It should be understood by those skilled in the art that various modifications, combinations, sub-combinations and substitutions can be made according to design requirements and other factors. Any modification, equivalent substitution and improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims

1. A method for determining the amount of crude oil cracking gas resources, characterized in that: include: Acquire geological data and experimental data of the work area, and determine the crude oil resource amount of the work area based on the geological data and the experimental data; Acquiring a work area parameter of the work area, and determining the crude oil cracking gas resource amount of the work area based on the work area parameter and the crude oil resource amount; Wherein, the experimental data is data obtained after a heating rate experiment is performed on a sample, and the sample includes a source rock sample obtained from the work area; The work area parameters include parameters describing the properties of the work area.

2. The method according to claim 1, characterized in that The working area parameters include at least crude oil cracking rate and natural gas density; The determining of the crude oil cracking gas resource based on the work area parameters and the crude oil resource comprises: Determine the quality of natural gas according to the crude oil resource and the crude oil cracking rate, wherein the quality of natural gas is the quality of natural gas generated after the crude oil in the work area is cracked; Determining the volume of the natural gas according to the density of the natural gas and the mass of the natural gas; Based on the natural gas volume, the crude oil cracking gas resource volume is determined.

3. The method according to claim 2, characterized in that The work area parameters also include natural gas molar mass of natural gas components, crude oil density, asphalt density, crude oil volume coefficient, molar gas constant, gas reservoir temperature, gas reservoir initial pressure and compressibility factor of natural gas components at the gas reservoir initial pressure; The step of determining the amount of crude oil cracking gas resources based on the natural gas volume includes: Determining a natural gas loss coefficient according to the crude oil cracking rate, the natural gas molar mass, the crude oil density, the asphalt density, the crude oil volume coefficient, the molar gas constant, the gas reservoir temperature, the gas reservoir initial pressure and the compression factor; The amount of crude oil cracking gas resources is determined based on the natural gas loss coefficient and the natural gas volume.

4. The method according to claim 1, characterized in that: The determining of the crude oil resource amount of the work area based on the geological data and the experimental data comprises: Based on the geological data and the experimental data, a three-dimensional geological model of the work area is established; Based on the three-dimensional geological model, determining the total oil production and oil potential data of the work area; The crude oil resource volume of the work area is determined based on the total oil production, the oil potential data and the geological data.

5. The method according to claim 4, characterized in that The step of establishing a three-dimensional geological model of the work area based on the geological data and the experimental data includes: Obtaining the vitrinite reflectance of the work area; Based on the geological data, determining the work area data of the work area, wherein the work area data includes at least one of the following: ground topography data, stratum thickness data, stratum age data, source rock thickness data, source rock total organic carbon distribution data, erosion data, mixed lithology data, paleo-water depth data, paleo-heat flow data, and paleo-geothermal data; Determining hydrocarbon generation kinetic parameters based on the experimental data; A three-dimensional geological model of the work area is established based on the vitrinite reflectance, the hydrocarbon generation kinetic parameters, and the work area data.

6. The method according to claim 4, characterized in that The determining of the crude oil resource volume of the work area based on the total oil production, the oil potential data and the geological data comprises: Determine the stratigraphic structure data of the work area according to the geological data; According to the oil potential data and the stratigraphic structure data, the work area is divided to obtain at least one migration and accumulation unit; Determining the unit oil production of each transport and accumulation unit in the at least one transport and accumulation unit according to the total oil production; Based on the geological data, determining a unit migration coefficient of each migration unit; The crude oil resource volume of the work area is determined according to the unit oil production and unit migration and accumulation coefficient of each migration and accumulation unit.

7. The method according to claim 6, characterized in that The step of determining the unit migration coefficient of each migration unit based on the geological data comprises: Determining a scale unit from the at least one migration unit based on the geological data; Based on the geological data, determine the calibration resource of the calibration unit by statistical method or analogy method, wherein the calibration resource is the resource of crude oil in the calibration unit; Determining the scale migration and accumulation coefficient of the scale unit according to the scale resource amount and the scale oil production amount of the scale unit, wherein the scale oil production amount is the unit oil production amount of the scale unit; Based on the scaled migration coefficient and the geological data, a unit migration coefficient of each migration unit is determined.

8. A crude oil cracking gas resource determination device, characterized in that: include: A crude oil resource determination module, used to obtain geological data and experimental data of a work area, and determine the crude oil resource of the work area based on the geological data and the experimental data; A crude oil cracking gas resource quantity determination module, used for obtaining the work area parameters of the work area, and determining the crude oil cracking gas resource quantity of the work area based on the work area parameters and the crude oil resource quantity; Wherein, the experimental data is data obtained after a heating rate experiment is performed on a sample, and the sample includes a source rock sample obtained from the work area; The work area parameters include parameters describing the properties of the work area.

9. An electronic device, characterized in that: include: at least one processor; as well as a memory communicatively connected to the at least one processor; wherein, The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor executes the method for determining the amount of crude oil cracking gas resources as described in any one of claims 1-7.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the method for determining the amount of crude oil cracking gas resources as described in any one of claims 1-7 when executed.

Images